Regional transmission organization

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A regional transmission organization (RTO) in the United States is an organization that is responsible for moving electricity over large interstate areas. Like the European transmission system operator (TSO), an RTO coordinates, controls and monitors an electricity transmission grid.

An independent system operator (ISO) is an organization formed at the direction or recommendation of the Federal Energy Regulatory Commission (FERC). In the areas where an ISO is established, it coordinates, controls and monitors the operation of the electrical power system, usually within a single US State, but sometimes encompassing multiple states. RTOs typically perform the same functions as ISOs, but cover a larger geographic area.

A more detailed explanation of the differences between an RTO and an ISO is available at: ISO RTO.

RTOs were created by the Federal Energy Regulatory Commission (FERC) Order No. 2000, Issued on December 29, 1999.


In Order 2000, the Federal Energy Regulatory Commission defined a Regional Transmission Organization as having four minimum characteristics and eight minimum functions.[1]


  1. Independence – an RTO should be independent from its market participants in financial interests, decision-making, and tariff-setting.
  2. Scope and regional configuration – the region for an RTO should be chosen to achieve the necessary regulatory, reliability, operational, and competitive benefits.
  3. Operational authority – an RTO must have the authority to control its transmission facilities (e.g. switching elements in and out of service, monitoring and controlling voltage) and must be the security coordinator for its region.
  4. Short-term reliability – an RTO must ensure the region meets the NERC reliability standards or alert FERC if it does not.


  1. Tariff administration and design – in order to ensure don-discriminatory transmission service, an RTO must be the sole provider of transmission service and sole administrator of its own open access tariff.
  2. Congestion management – an RTO must ensure the development and operation of market mechanisms to manage transmission congestion.
  3. Parallel path flow – an RTO must develop and implement procedures to address parallel path flow issues within its region and with other regions.
  4. Ancillary services – an RTO must serve as the supplier of last resort for all ancillary services and determine if the minimum amount of ancillary services have been supplied according to FERC Order No. 888.
  5. OASIS and Total Transmission Capability (TTC) and Available Transmission Capability (ATC) – an RTO must be the single OASIS site administrator for all transmission facilities under its control and independently calculate TTC and ATC.
  6. Market monitoring – an RTO must monitor market behavior and report market power abuses and market design flaws to FERC.
  7. Planning and expansion – an RTO must have ultimate responsibility for both transmission planning and expansion within its region that will enable it to provide efficient, reliable and non-discriminatory service.
  8. Interregional coordination – an RTO must coordinate its activities with other regions.

Only electric utilities that are located within the United States fall under FERC authority, but a larger organization called the North American Electric Reliability Corporation (NERC) overlays the entire FERC footprint and also includes a Mexican utility and several Canadian utilities. As such, international reciprocity is commonplace, and rules or recommendations introduced by FERC often are voluntarily accepted by NERC members outside of FERC’s jurisdiction. Therefore, one Canadian Province is a member of a U.S.-based RTO, while two others function as an Electric System Operator (ESO), an organization essentially equal to a U.S.-based ISO.

Some ISOs and RTOs also act as a marketplace in wholesale power, especially since the electricity market deregulation of the late 1990s. Most are set up as nonprofit corporations using governance models developed by FERC.

FERC Orders 888 and 889 defined how independent power producers (IPPs) and power marketers would be allowed fair access to transmission systems, and mandated the implementation of the Open Access Same-Time Information System (OASIS) to facilitate the fair handling of transactions between electric power transmission suppliers and their customers.

TSOs in Europe cross state and provincial borders like RTOs.

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RTOs were created by the Federal Energy Regulatory Commission (FERC) as a way to handle the challenges associated with the operation of multiple interconnected independent power supply companies. FERC describes this as a voluntary system. The traditional model of the vertically integrated electric utility with a transmission system designed to serve its own customers worked extremely well for decades. As dependence on a reliable supply of electricity grew and electricity was transported over increasingly greater distances, power pools were formed and interconnections developed. Transactions were relatively few and generally planned well in advance.

However, in the last decade of the 20th century, some policy makers and academics projected that the electrical power industry would ultimately experience deregulation, and RTOs were conceived as the way to handle the vastly increased number of transactions that take place in a competitive environment. About a dozen states decided to deregulate but some pulled back following the California electricity crisis of 2000 and 2001.

RTOs ensure three key free marketer drives: open access and non-discriminatory services, the continued reliability of a system unequalled anywhere else, and multiple transmission charges that will not negate the savings to the end-use customer. Critics of RTOs counter that the wholesale electricity market as operated through the RTOs is in fact raising prices beyond what would obtain in a truly competitive situation, and that the organizations themselves add a needless layer of bureaucracy.[citation needed]

The RTO concept provides for separation of generation and transmission and elimination of pancaked rates, and it encourages a diverse membership including public power. Wider membership contributes to the establishment of an entity with the size necessary to function as an RTO.


In the 1990s, as states and regions in the United States established wholesale competition for electricity, groups of utilities and their federal and state regulators began forming independent transmission operators that would ensure equal access to the power grid for non-utility firms, enhance the reliability of the transmission system and operate wholesale electricity markets. Today, seven of these grid operators, either independent system operators (ISOs) or RTOs, coordinate the power grid to ensure the reliable delivery of two-thirds of the electricity used in the United States to two-thirds of its population. Most are overseen by FERC.

ISOs and RTOs coordinate generation and transmission across wide geographic regions, matching generation to the load instantaneously to keep supply and demand for electricity in balance. The grid operators forecast load and schedule generation to assure that sufficient generation and back-up power is available in case demand rises or a power plant or power line is lost. They also operate wholesale electricity markets that enable participants to buy and sell electricity on a day-ahead or a real-time spot market basis. These markets provide electricity suppliers with more options for meeting consumer needs for power at the lowest possible cost.

ISO/RTOs provide non-discriminatory transmission access, facilitating competition among wholesale suppliers to improve transmission service and provide fair electricity prices. Across large regions, they schedule the use of transmission lines; manage the interconnection of new generation and monitor the markets to ensure fairness and neutrality for all participants. Providing these services regionally is more efficient than providing them on a smaller-scale, utility by utility.

Today’s power industry is far more than a collection of power plants and transmission lines. Maintaining an effective grid requires management of three different but related sets of flows – the flow of energy across the grid; the exchange of information about power flows and the equipment it moves across; and the flow of money between producers, marketers, transmission owners, buyers and others. ISO/RTOs play an essential role in managing and enhancing all three of these flows.

List of RTOs[edit]

As of 2012 there are ten ISO/RTOs operating in North America:[1][2]

Non-RTO transmission organizations:

  • ColumbiaGrid
  • Northern Tier Transmission Group


ColumbiaGrid, a nonprofit corporation, is not a regional transmission organization (RTO) and has no plans to become one, but instead seeks to achieve many of the benefits of an RTO through incremental additions to its functions. ColumbiaGrid was formed after some of its members chose not to continue in efforts to form Grid West, a Northwest evolutionary structure with the ability to add functions and to move toward independent grid management. The ColumbiaGrid members, including the Bonneville Power Administration, several Washington State public utilities and two investor-owned utilities, wanted an organization with more limited functions and no independent ability to change. ColumbiaGrid performs single-utility transmission planning and expansion via an open and transparent process and is also establishing a multi-system OASIS portal.

The former Grid West participants who had argued for an eventual RTO, mainly investor-owned utilities and state representatives from Oregon, Idaho, Montana, Wyoming and Utah, formed the Northern Tier Transmission Group (NTTG), a nascent effort open to evolution but initially focused on inexpensive and relatively easy improvements to grid management, including area control error (ACE) diversity interchange, currently underway; transparent methodologies for calculating available transmission capacity; and planning, as required by FERC Order 890.

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